File Pursuant to Rule 424(b)(1)

Registration No. 333-145386

 

 

Prospectus

59,821,049 Shares

 

 

SandRidge Energy, Inc.

 

Common Stock

 

 

 

 

This prospectus relates to up to 59,821,049 shares of the common stock of SandRidge Energy, Inc., which may be offered for sale by the selling stockholders named in this prospectus. The shares of common stock offered by this prospectus were acquired by the selling stockholders, or are issuable upon conversion of securities acquired by the selling stockholders, in connection with our December 2005, November 2006 and March 2007 private placements. We are registering the offer and sale of the shares of common stock to satisfy registration rights we have granted.

 

We are not selling any shares of common stock under this prospectus and will not receive any proceeds from the sale of common stock by the selling stockholders. The shares of common stock to which this prospectus relates may be offered and sold from time to time directly from the selling stockholders or alternatively through underwriters or broker-dealers or agents. The shares of common stock may be sold in one or more transactions, at fixed prices, at prevailing market prices at the time of sale or at negotiated prices. Please read “Plan of Distribution.”

 

 

 

 

Our common stock is listed on the New York Stock Exchange under the symbol “SD.”

 

 

 

 

Investing in our common stock involves a high degree of risk. See “Risk Factors” beginning on page 13.

 

 

Neither the Securities and Exchange Commission nor any state securities commission has approved or disapproved these securities or determined if this prospectus is accurate or complete. Any representation to the contrary is a criminal offense.

 

 

 

 

The date of this prospectus is January 4, 2008

TABLE OF CONTENTS

 

 

You should rely only on the information contained in this prospectus or to which we have referred you. We and the selling stockholders have not authorized anyone to provide you with different information. We and the selling stockholders are not making an offer of these securities in any jurisdiction where such offer or sale is not permitted. You should assume that the information contained in this prospectus is accurate as of the date on the front of this prospectus only. Our business, financial condition, results of operations and prospects may have changed since that date.

 

This prospectus is part of a “shelf” registration statement that we filed with the Securities and Exchange Commission (the “SEC”) for a continuous offering. Under this prospectus, the selling stockholders may, from time to time, sell the shares of our common stock described in this prospectus in one or more offerings. This prospectus may be supplemented from time to time to add, update or change information in this prospectus. Any statement contained in this prospectus will be deemed to be modified or superseded for the purposes of this prospectus to the extent that a statement contained in a prospectus supplement modifies such statement. Any statement so modified will be deemed to constitute a part of this prospectus only as so modified, and any statement so modified will be deemed to constitute a part of this prospectus.

The registration statement containing this prospectus, including the exhibits to the registration statement, provides additional information about us, the selling stockholders and the shares of our common stock offered under this prospectus. The registration statement, including the exhibits, can be read on the SEC website or at the SEC offices mentioned under the heading “Where You Can Find More Information.”

 

Information contained in our website does not constitute part of this prospectus.

 

SandRidge Energy, Inc., our logo and other trademarks mentioned in this prospectus are the property of their respective owners.

 

This prospectus includes market share and industry data that we obtained from internal research, publicly available information and industry publications and surveys. Our internal research and forecasts are based upon management’s understanding of industry conditions. Industry surveys and publications generally state that the information contained therein has been obtained from sources believed to be reliable.

	•	Grow Through Exploration and Aggressive Drilling and Development of Existing Acreage.  We expect to generate long-term reserve and production growth by exploring and aggressively drilling and developing our large acreage position. Our primary exploration and development focus will be in the WTO, where we have identified over 2,600 potential drilling locations and had 30 rigs operating as of September 30, 2007.
	•	Apply Technological Improvements to Our Exploration and Development Program.  We intend to enhance our drilling success rate and completion efficiency with improved 3-D seismic acquisition and interpretation technologies, together with advanced drilling, completion and production methods that historically have not been widely used in the under-explored WTO.

	•	Seek Opportunistic Acquisitions in Our Core Geographic Area.  Since January 2006, through acquisitions and leasing activities, we have nearly tripled our net acreage position in the WTO. We intend to continue to seek other opportunities to optimize and enhance our exploratory acreage position in the WTO and other strategic areas.

	•	Reduce Costs, Enhance Returns and Maintain Operating Flexibility by Controlling Drilling Rigs and Midstream Assets.  Our rig fleet enables us to aggressively develop our own acreage while maintaining the flexibility of a third-party contract drilling business. By controlling our fleet of drilling rigs and gathering and treating assets, we believe we will be able to better control overall costs and maintain a high degree of operational flexibility.
	•	Capture and Utilize CO2 for Tertiary Oil Recovery.  We intend to capitalize on our access to CO2 reserves and CO2 flooding expertise to pursue enhanced oil recovery in mature oil fields in West Texas. By utilizing this CO2 in our own tertiary recovery projects, we expect to recover additional oil that would have otherwise been abandoned following traditional waterfloods.

	•	Large Asset Base with Substantial Drilling Inventory.  Our producing properties are characterized by long-lived predominantly natural gas reserves with established production profiles. Our estimated proved reserves of 1,174.0 Bcfe as of June 30, 2007 had a proved reserves to production ratio of

		approximately 19 years. Our core area of operations in the WTO has expanded to 581,961 gross (480,721 net) acres as of June 30, 2007. We have identified over 2,600 potential drilling locations in the WTO and believe that we will be able to expand the number of drilling locations in the remainder of the WTO through exploratory drilling and our use of 3-D seismic technology.

	•	Geographically Concentrated Exploration and Development Operations.  We intend to focus our drilling and development operations in the near term on the WTO to fully exploit this unique geological region. This geographic concentration allows us to establish economies of scale in both drilling and production operations to achieve lower production costs and generate increased cash flows from our producing properties. We believe our concentrated acreage position will enable us to organically grow our reserves and production for the next several years.
	•	Experienced Management Team Focused on Delivering Long-term Stockholder Value.  During 2006, we significantly expanded our management team when Tom L. Ward, co-founder and former president of Chesapeake, purchased a significant interest in us and became our Chairman and Chief Executive Officer. We also hired a new chief financial officer, three additional executive vice presidents and other additional senior executives. Our management team, board of directors and employees owned over 35% of our capital stock on a fully-diluted basis as of November 30, 2007, which we believe aligns their objectives with those of our stockholders.
	•	High Degree of Operational Control.  We operate over 95% of our production in the WTO, East Texas and the Gulf Coast area, which permits us to manage our operating costs and better control capital expenditures and the timing of development and exploitation activities.
	•	Large Modern Fleet of Drilling Rigs.  By controlling a large, modern and more efficient drilling fleet, we can develop our existing reserves and explore for new reserves on a more economic basis.

																										Number of
		Estimated																								Identified
		Net Proved								Daily				Proved												Potential
		Reserves				PV-10 (in				Production				Reserves/				Gross				Net				Drilling
Area		(Bcfe)(1)				millions)(1)(2)				(Mmcfe/d)(3)				Production(1)				Acreage				Acreage				Locations(1)
WTO			648.3			$	1,190.9				69.1				25.7	(4)			581,961				480,721				2,658
East Texas			156.3				310.2				26.3				16.3				48,606				32,557				566
Gulf Coast			104.5				410.7				44.2				6.6				53,464				34,765				51
Other(5)			265.9				646.9				37.1				19.5				428,200				214,989				1,298	(6)
Total			1,174.0			$	2,558.8				176.7				18.2				1,112,231				763,032				4,573

(1)		Estimated net proved reserves, PV-10 and identified potential drilling locations are as of June 30, 2007.
(2)		PV-10 generally differs from Standardized Measure of Discounted Net Cash Flows, or Standardized Measure, which is measured only at fiscal year end, because it does not include the effects of income taxes on future net revenues. For a reconciliation of PV-10 to Standardized Measure as of December 31, 2006, see “Summary Historical Operating and Reserve Data.” Our Standardized Measure was $1,440.2 million at December 31, 2006.

(3)		Represents average daily net production for the third quarter 2007.
(4)		Our proved reserves to production ratio in the WTO is significantly higher than our other areas of operation because of the high volume of our proved undeveloped reserves in this area. We expect this ratio to decrease as our production in the WTO increases.
(5)		Includes our properties located offshore in the Gulf of Mexico, the Piceance Basin of Colorado, Other West Texas areas, including our tertiary oil recovery projects, and the Arkoma and Anadarko Basins and other non-strategic areas.
(6)		Includes 828 identified potential drilling locations in the Piceance Basin.

	•	South Sabino Prospect Area.  The South Sabino prospect area is located approximately twelve miles east of the Piñon Field. We have drilled two wells that appear to be on trend with the Piñon Field and are structurally higher against one of several thrust faults that make up the WTO. We began the first phase of our 3-D seismic program in this area in 2007 and may drill additional wells in late 2007 following the integration of this data and new subsurface well control.

	•	Big Canyon Prospect Area.  Located approximately 20 miles east of the Piñon Field along the WTO, this prospect area represents potential opportunities for future development. We plan to conduct a 3-D seismic survey over the Big Canyon prospect area as part of Phase II of our 3-D seismic program in 2007. Exploratory wells may be planned in late 2007 and early 2008 to further evaluate both the Tesnus and the Caballos in a location structurally updip to the Big Canyon Ranch 106-1 well.

2007

Estimated

Total Gross

Capital

2006

Estimated Net

Gross PUD

Gross PUD

Drilling

Gross 2007

Expenditures

Year

Rigs

PUD Reserves

Reserves

Drilling

Locations

Drilling

Budget

End Rigs

Working at 3Q

(Bcfe)(1)

(Bcfe)(1)

Locations(1)

(1)

Locations

(in millions)(2)

Working

2007 End

431.1

675.2

406

2,658

207

$

537

9

30

(1)		As of June 30, 2007.
(2)		Excludes capital expenditures related to land and seismic acquisitions.

Repayment of outstanding balance on senior credit facility		$	515.9
Repayment of note payable and accrued interest incurred in connection with recent acquisition			49.1
Excess cash to fund future capital expenditures			230.3
Total		$	795.3

	•	natural gas and oil prices are volatile, and a decline in natural gas and oil prices can significantly affect our financial results and impede our growth;
	•	our estimated reserves are based on many assumptions that may turn out to be inaccurate, and any significant inaccuracies in these reserve estimates or underlying assumptions will materially affect the quantities and present value of our reserves;
	•	unless we replace our natural gas and oil reserves, our reserves and production will decline, which would adversely affect our business, financial condition and results of operations;
	•	our potential drilling location inventories are scheduled out over several years, making them susceptible to uncertainties that could materially alter the occurrence or timing of their drilling;
	•	the development of the proved undeveloped reserves in the WTO may take longer and may require higher levels of capital expenditures than we currently anticipate;
	•	a significant portion of our operations are located in the WTO, making us vulnerable to risks associated with operating in one major geographic area;
	•	we have a substantial amount of indebtedness, which may adversely affect our cash flow and our ability to operate our business; and
	•	certain stockholders’ shares are restricted from immediate resale but may be sold into the market in the near future, which could cause the market price of our common stock to drop significantly.

Common stock offered by the selling stockholders(1)		59,821,049 shares
Common stock outstanding(2)		141,845,661 shares
Common Stock to be outstanding assuming the conversion of our convertible preferred stock		164,121,472 shares
Dividend policy		We do not anticipate that we will pay cash dividends in the foreseeable future.
Use of Proceeds		We will not receive any proceeds from the sale of the shares of common stock by the selling stockholders.
New York Stock Exchange Symbol		“SD”

(1)	See “Selling Stockholders” for information on the selling stockholders.
(2)	As of November 30, 2007. The shares exclude 22,275,871 shares issuable upon conversion of our convertible preferred stock and the exercise of all warrants for convertible preferred stock.

		Historical																				Pro Forma
																						Nine Months
														Nine Months Ended								Ended				Year Ended
		Years Ended December 31,												September 30,								September 30,				December 31,
		2004(1)				2005				2006				2006				2007				2006				2006
		(In thousands)
Statement of Operations Data:
Revenues		$	175,995			$	287,693			$	388,242			$	263,177			$	461,775			$	439,557			$	565,256
Expenses:
Production			10,230				16,195				35,149				21,625				77,707				64,009				84,895
Production taxes			2,497				3,158				4,654				2,579				12,328				2,579				9,770
Drilling and services			26,442				52,122				98,436				72,670				30,935				56,556				77,453
Midstream and marketing			96,180				141,372				115,076				85,525				61,191				44,307				66,848
Depreciation, depletion and amortization — natural gas and crude oil			4,909				9,313				26,321				13,932				115,876				174,101				217,013
Depreciation, depletion and amortization — other			7,765				14,893				29,305				22,106				36,545				22,106				29,701
General and administrative			6,554				11,908				55,634				32,024				45,781				38,126				67,629
Loss (gain) on derivative contracts			878				4,132				(12,291	)			(16,176	)			(55,228	)			(107,039	)			(111,998	)
Loss (gain) on sale of assets			(210	)			547				(1,023	)			(849	)			(1,704	)			(851	)			(1,023	)
Total expenses			155,245				253,640				351,261				233,436				323,431				293,894				440,288
Income from operations			20,750				34,053				36,981				29,741				138,344				145,663				124,968
Other income (expense):
Interest income			56				206				1,109				448				4,201				5,236				5,984
Interest expense			(1,678	)			(5,277	)			(16,904	)			(4,090	)			(88,630	)			(59,774	)			(74,056	)
Minority interest			(262	)			(737	)			(296	)			(281	)			(321	)			(170	)			(185	)
Income (loss) from equity investments			(36	)			(384	)			967				40				3,399				40				967
Total other income (expense)			(1,920	)			(6,192	)			(15,124	)			(3,883	)			(81,351	)			(54,668	)			(67,290	)
Income before income taxes			18,830				27,861				21,857				25,858				56,993				90,995				57,678
Income tax expense			6,433				9,968				6,236				6,931				21,002				33,668				21,341
Income from continuing operations			12,397				17,893				15,621				18,927				35,991				57,327				36,337
Income from discontinued operations, net of tax			451				229				—				—				—				—				—
Extraordinary gain			12,544				—				—				—				—				—				—
Net income			25,392				18,122				15,621				18,927				35,991				57,327				36,337
Preferred stock dividends and accretion			—				—				3,967				—				30,573				27,155				40,174
Income (loss) available (applicable) to common stockholders		$	25,392			$	18,122			$	11,654			$	18,927			$	5,418			$	30,172			$	(3,837	)

		Historical																				Pro Forma
																						Nine Months
														Nine Months Ended								Ended				Year Ended
		Years Ended December 31,												September 30,								September 30,				December 31,
		2004(1)				2005				2006				2006				2007				2006				2006
		(In thousands except per share data)
Earnings Per Share Information:
Basic
Income from continuing operations		$	0.22			$	0.31			$	0.21			$	0.26			$	0.35			$	0.47			$	0.30
Income from discontinued operations, net of income tax			0.01				0.01				—				—				—				—				—
Extraordinary gain on acquisition			0.22				—				—				—				—				—				—
Preferred stock dividends			—				—				(0.05	)			—				(0.30	)			(0.22	)			(0.33	)
Income (loss) per share available (applicable) to common stockholders		$	0.45			$	0.32			$	0.16			$	0.26			$	0.05			$	0.25			$	(0.03	)
Weighted average number of shares outstanding(2):			56,312				56,559				73,727				71,692				102,562				122,429				122,426
Diluted
Income from continuing operations		$	0.22			$	0.31			$	0.21			$	0.26			$	0.35			$	0.47			$	0.30
Income from discontinued operations, net of income tax			0.01				0.01				—				—				—				—				—
Extraordinary gain on acquisition			0.22				—				—				—				—				—				—
Preferred stock dividends			—				—				(0.05	)			—				(0.30	)			(0.22	)			(0.33	)
Income (loss) per share available (applicable) to common stockholders		$	0.45			$	0.32			$	0.16			$	0.26			$	0.05			$	0.25			$	(0.03	)
Weighted average number of outstanding shares(2):			56,312				56,737				74,664				72,633				103,778				123,370				123,363

(1)		We recognized an extraordinary gain from the recognition of the excess of fair value over acquisition cost of $12.5 million related to an acquisition we made in 2004.
(2)		The number of shares has been adjusted to reflect a 281.552-to-1 stock split in December 2005.

		Historical
		At December 31,								At September 30,
		2005				2006				2007
		(In thousands)
Balance Sheet Data:
Cash and cash equivalents		$	45,731			$	38,948			$	32,013
Property, plant and equipment, net		$	337,881			$	2,134,718			$	2,889,495
Total assets		$	458,683			$	2,388,384			$	3,170,456
Long-term debt		$	43,133			$	1,066,831			$	1,451,504
Redeemable convertible preferred stock		$	—			$	439,643			$	450,356
Total stockholders’ equity		$	289,002			$	649,818			$	965,123
Total liabilities and stockholders’ equity		$	458,683			$	2,388,384			$	3,170,456

		At December 31,				At December 31,				At June 30,
		2005				2006				2007
Estimated Proved Reserves(1)
Natural Gas (Bcf)(2)			237.4				850.7				967.6
Oil (MmBbls)			10.4				25.2				34.4
Total (Bcfe)			300.0				1,001.8				1,174.0
PV-10 (in millions)		$	733.3	(3)		$	1,734.3	(3)		$	2,558.8	(3)
Standardized Measure of Discounted Net Cash Flows (in millions)(4)		$	499.2			$	1,440.2				n/a	(5)

(1)		Our estimated proved reserves and the future net revenues, PV-10, and Standardized Measure of Discounted Net Cash Flows were determined using end of the period prices for natural gas and oil that we realized as of December 31, 2005, December 31, 2006 and June 30, 2007, which were $8.40 per Mcf of natural gas and $54.04 per barrel of oil at December 31, 2005, $5.64 per Mcf of natural gas and $57.75 per barrel of oil at December 31, 2006 and $6.70 per Mcf of natural gas and $63.78 per barrel of oil at June 30, 2007.
(2)		Given the nature of our natural gas reserves, a significant amount of our production, primarily in the WTO, contains natural gas high in CO2 content. These figures are net of volumes of CO2 in excess of pipeline quality specifications.
(3)		PV-10 is a non-GAAP financial measure and represents the present value of estimated future cash inflows from proved natural gas and oil reserves, less future development and production costs, discounted at 10% per annum to reflect timing of future cash flows and using pricing assumptions in effect at the end of the period. PV-10 differs from Standardized Measure of Discounted Net Cash Flows because it does not include the effects of income taxes and other items on future net revenues. Neither PV-10 nor Standardized Measure represent an estimate of fair market value of our natural gas and oil properties. PV-10 is used by the industry and by our management as an arbitrary reserve asset value measure to compare against past reserve bases and the reserve bases of other business entities that are not dependent on the taxpaying status of the entity.
		The following table provides a reconciliation of our Standardized Measure to PV-10:

		At December 31,				At December 31,
		2005				2006
		(In millions)
Standardized Measure of Discounted Net Cash Flows		$	499.2			$	1,440.2
Present value of future income tax and other discounted at 10%			234.1				294.1
PV-10		$	733.3			$	1,734.3

(4)		The Standardized Measure of Discounted Net Cash Flows represents the present value of estimated future cash inflows from proved natural gas and oil reserves, less future development and production costs, and income tax expenses, discounted at 10% per annum to reflect timing of future cash flows and using the same pricing assumptions as were used to calculate PV-10. Standardized Measure differs from PV-10 because Standardized Measure includes the effect of future income taxes and other items.
(5)		Standardized Measure of Discounted Net Cash Flows is only calculated at fiscal year end under applicable accounting rules.

														Nine Months
														Ended
		Year Ended December 31,												September 30,
		2004				2005				2006				2006				2007
Production Data:
Natural Gas (Mmcf)			6,708				6,873				13,410				6,856				35,148
Oil (MBbls)			37				72				322				70				1,441
Combined Equivalent Volumes (Mmcfe)			6,930				7,305				15,342				7,275				43,793
Average Daily Combined Equivalent Volumes (Mmcfe/d)			18.9				20.0				42.0				27				160

														Nine Months
														Ended
		Year Ended December 31,												September 30,
		2004				2005				2006				2006				2007
Average Prices(1):
Natural Gas (per Mcf)		$	4.43			$	6.54			$	6.19			$	6.14			$	6.56
Oil (per Bbl)		$	34.03			$	48.19			$	56.61			$	61.89			$	61.67
Combined Equivalent (per Mcfe)		$	4.47			$	6.63			$	6.60			$	6.38			$	7.30

(1)		Reported prices represent actual prices for the periods presented and do not give effect to hedging transactions.

														Nine Months
														Ended
		Year Ended December 31,												September 30,
		2004				2005				2006				2006				2007
Expenses per Mcfe:
Lease operating expenses:
Transportation		$	0.14			$	0.16			$	0.22			$	0.14			$	0.15
Processing and gathering(1)			0.39				0.42				0.37				0.33				0.30
Other lease operating expenses			0.94				1.64				1.70				2.50				1.32
Total lease operating expenses		$	1.48			$	2.22			$	2.29			$	2.97			$	1.77
Production taxes		$	0.36			$	0.43			$	0.30			$	.35			$	.28

(1)		Includes costs attributable to gas treatment to remove CO2 and other impurities from our high CO2 natural gas.

RISK FACTORS

 

An investment in our common stock involves a high degree of risk. You should carefully consider the following risks and all of the other information contained in this prospectus before deciding to invest in our common stock.

 

Risks Related to the Natural Gas and Oil Industry and Our Business

 

Natural gas and oil prices are volatile, and a decline in natural gas and oil prices can significantly affect our financial results and impede our growth.

 

Our revenue, profitability and cash flow depend upon the prices and demand for natural gas and oil. The markets for these commodities are very volatile. Even relatively modest drops in prices can significantly affect our financial results and impede our growth. Changes in natural gas and oil prices have a significant impact on the value of our reserves and on our cash flow. Prices for natural gas and oil may fluctuate widely in response to relatively minor changes in the supply of and demand for natural gas and oil and a variety of additional factors that are beyond our control, such as:

 

 

Lower natural gas and oil prices may not only decrease our revenues on a per share basis, but also may reduce the amount of natural gas and oil that we can produce economically. This may result in our having to make substantial downward adjustments to our estimated proved reserves.

 

Our estimated reserves are based on many assumptions that may turn out to be inaccurate. Any significant inaccuracies in these reserve estimates or underlying assumptions will materially affect the quantities and present value of our reserves.

 

The process of estimating natural gas and oil reserves is complex and inherently imprecise. It requires interpretations of available technical data and many assumptions, including assumptions relating to production rates and economic factors such as natural gas and oil prices, drilling and operating expenses, capital expenditures and availability of funds. Any significant inaccuracies in these interpretations or assumptions could materially affect the estimated quantities and present value of reserves shown in this prospectus. See “Business — Our Business and Primary Operations” for information about our natural gas and oil reserves.

 

Actual future production, natural gas and oil prices, revenues, taxes, development expenditures, operating expenses and quantities of recoverable natural gas and oil reserves most likely will vary from our estimates. Any significant variance could materially affect the estimated quantities and present value of reserves shown in this prospectus. In addition, we may adjust estimates of proved reserves to reflect production history, results

of exploration and development, prevailing natural gas and oil prices and other factors, many of which are beyond our control.

 

The present value of future net cash flows from our proved reserves will not necessarily be the same as the current market value of our estimated natural gas and oil reserves.

 

We base the estimated discounted future net cash flows from our proved reserves on prices and costs in effect on the day of estimate. Actual future net cash flows from our natural gas and oil properties also will be affected by factors such as:

 

 

The timing of both our production and our incurrence of expenses in connection with the development and production of natural gas and oil properties will affect the timing of actual future net cash flows from proved reserves, and thus their actual present value. In addition, the 10% discount factor we use when calculating discounted future net cash flows may not be the most appropriate discount factor based on interest rates in effect from time to time and risks associated with us or the natural gas and oil industry in general.

 

Unless we replace our natural gas and oil reserves, our reserves and production will decline, which would adversely affect our business, financial condition and results of operations.

 

Our future natural gas and oil reserves and production, and therefore our cash flow and income, are highly dependent on our success in efficiently developing and exploiting our current reserves and economically finding or acquiring additional recoverable reserves. We may not be able to develop, find or acquire additional reserves to replace our current and future production at acceptable costs.

 

Our potential drilling location inventories are scheduled over several years, making them susceptible to uncertainties that could materially alter the occurrence or timing of their drilling.

 

As of June 30, 2007, only 699 of our 4,573 identified potential future well locations were attributable to proved undeveloped reserves. These potential drilling locations, including those without proved undeveloped reserves, represent a significant part of our growth strategy. Our ability to drill and develop these locations is subject to a number of uncertainties, including the availability of capital, seasonal conditions, regulatory approvals, natural gas and oil prices, costs and drilling results. Because of these uncertainties, we do not know if the numerous potential drilling locations we have will ever be drilled or if we will be able to produce natural gas or oil from these or any other potential drilling locations. As such, our actual drilling activities may materially differ from our current expectations, which could adversely affect our business.

 

We will not know conclusively prior to drilling whether natural gas or oil will be present in sufficient quantities to be economically viable.

 

We describe some of our current prospects and drilling locations and our plans to explore those prospects and drilling locations in this prospectus. A prospect is a property on which we have identified what our geoscientists believe, based on available seismic and geological information, to be indications of natural gas or oil. Our prospects and drilling locations are in various stages of evaluation, ranging from a prospect that is ready to drill to a prospect that will require substantial additional seismic data processing and interpretation. The use of seismic data and other technologies and the study of producing fields in the same area will not enable us to know conclusively prior to drilling whether oil or natural gas will be present or, if present, whether oil or natural gas will be present in sufficient quantities to be economically viable. Even if sufficient amounts of oil or natural gas exist, we may damage the potentially productive hydrocarbon bearing formation

or experience mechanical difficulties while drilling or completing the well, resulting in a reduction in production from the well or abandonment of the well. From January 1, 2007 through September 30, 2007, we participated in drilling a total of 189 gross wells, of which six have been identified as a dry hole. If we drill additional wells that we identify as dry holes in our current and future prospects, our drilling success rate may decline and materially harm our business. In sum, the cost of drilling, completing and operating any well is often uncertain, and new wells may not be productive.

 

Properties that we buy may not produce as projected, and we may be unable to determine reserve potential, identify liabilities associated with the properties or obtain protection from sellers against them.

 

Our reviews of properties we acquire are inherently incomplete because it generally is not feasible to review in depth every individual property involved in each acquisition. Even a detailed review of records and properties may not necessarily reveal existing or potential problems, nor will it permit a buyer to become sufficiently familiar with the properties to assess fully their deficiencies and potential. Inspections may not always be performed on every well, and environmental problems, such as soil or ground water contamination, are not necessarily observable even when an inspection is undertaken. Even when problems are identified, we often assume certain environmental and other risks and liabilities in connection with acquired properties, which risks and liabilities could have a material adverse effect on our results of operations and financial condition.

 

The development of the proved undeveloped reserves in the WTO and other areas of operation may take longer and may require higher levels of capital expenditures than we currently anticipate.

 

Approximately 66% of the estimated proved reserves that we own or have under lease in the WTO as of June 30, 2007 are proved undeveloped reserves and 62% of our total reserves are proved undeveloped reserves. Development of these reserves may take longer and require higher levels of capital expenditures than we currently anticipate. Therefore, ultimate recoveries from these fields may not match current expectations. Delays in the development of our reserves or increases in costs to drill and develop such reserves will reduce the PV-10 value of our estimated proved undeveloped reserves and future net revenues estimated for such reserves.

 

A significant portion of our operations are located in WTO, making us vulnerable to risks associated with operating in one major geographic area.

 

As of June 30, 2007, approximately 55% of our proved reserves and approximately 40% of our production were located in the WTO. In addition, a substantial portion of our WTO natural gas contains a high concentration of CO₂ and requires treating. As a result, we may be disproportionately exposed to the impact of delays or interruptions of production from these wells caused by transportation and treatment capacity constraints, curtailment of production or treatment plant closures for scheduled maintenance or unanticipated occurrences.

 

Many of our prospects in the WTO may contain natural gas that is high in CO₂ content, which can negatively affect our economics.

 

The reservoirs of many of our prospects in the WTO may contain natural gas that is high in CO₂ content. The natural gas produced from these reservoirs must be treated for the removal of CO₂ prior to marketing. If we cannot obtain sufficient capacity at treatment facilities for our natural gas with a high CO₂ concentration, or if the cost to obtain such capacity significantly increases, we could be forced to delay production and development or experience increased production costs.

 

Furthermore, when we treat the gas for the removal of CO₂, some of the methane is used to run the treatment plant as fuel gas and other methane and heavier hydrocarbons, such as ethane, propane and butane, cannot be separated from the CO₂ and is lost. This is known as plant shrink. Historically our plant shrink has been approximately 14% in the WTO. We do not know the amount of CO₂ we will encounter in any well until it is drilled. As a result, sometimes we encounter CO₂ levels in our wells that are higher than expected. The

amount of CO₂ in the gas produced affects the heating content of the gas. For example, if a well is 65% CO₂, the gas produced often has a heating content of between 300 and 350 MBtu per Mcf. Giving consideration for plant shrink, as many as four Mcf of high CO₂ gas must be produced to sell one MmBtu of natural gas. We report our volumes of natural gas reserves and production net of CO₂ volumes that are removed prior to sales. Since the treatment expenses are incurred on an Mcf basis, we will incur a higher effective treating cost per MmBtu of natural gas sold for natural gas with a higher CO₂ content. As a result, high CO₂ gas wells must produce at much higher rates than low CO₂ gas wells to be economic, especially in a low natural gas price environment.

 

We may experience difficulty in staffing and retaining employees on our new drilling rigs, which may adversely affect the efficiency of our drilling program.

 

We have increased our number of drilling rigs and the level of our activity substantially. This has required us to add additional employees to staff our drilling rigs and to add professional and support staff to other departments. If we are unable to retain these employees, we may experience decreased efficiency and delays in our drilling program.

 

A significant decrease in natural gas production in our areas of midstream gas services operation, due to the decline in production from existing wells, depressed commodity prices or otherwise, would adversely affect our revenues and cash flow for our midstream gas services segment.

 

The profitability of our midstream business is materially impacted by the volume of natural gas we gather, transmit and process at our facilities. Most of the reserves backing up our midstream assets are operated by our exploration and production segment. A material decrease in natural gas production in our areas of operation would result in a decline in the volume of natural gas delivered to our pipelines and facilities for gathering, transmitting and processing. The effect of such a material decrease would be to reduce our revenues, operating income and cash flows. Fluctuations in energy prices can greatly affect production rates and investments by our exploration and production business and third-parties in the development of new natural gas and oil reserves. Drilling activity generally decreases as natural gas and oil prices decrease. We have no control over factors affecting production activity, including prevailing and projected energy prices, demand for hydrocarbons, the level of reserves, geological considerations, governmental regulation and the availability and cost of capital. Failure to connect new wells to our gathering systems would, therefore, result in the amount of natural gas we gather, transmit and process being reduced substantially over time and could, upon exhaustion of the current wells, cause us to abandon our gathering systems and, possibly cease gathering, transmission and processing operations. Our ability to connect to new wells will be dependent on the level of drilling activity in our areas of operations and competitive market factors. As a consequence of these declines, our revenues and cash flows could be materially adversely affected.

 

Our use of 2-D and 3-D seismic data is subject to interpretation and may not accurately identify the presence of natural gas and oil, which could adversely affect the results of our drilling operations.

 

A significant aspect of our exploration and development plan involves seismic data. Even when properly used and interpreted, 2-D and 3-D seismic data and visualization techniques are only tools used to assist geoscientists in identifying subsurface structures and hydrocarbon indicators and do not enable the interpreter to know whether hydrocarbons are present in those structures. Other geologists and petroleum professionals, when studying the same seismic data, may have significantly different interpretations than our professionals. In addition, the use of 2-D and 3-D seismic and other advanced technologies requires greater predrilling expenditures than traditional drilling strategies, and we could incur losses due to such expenditures. As a result, our drilling activities may not be geologically successful or economical, and our overall drilling success rate or our drilling success rate for activities in a particular area may not improve.

 

We often gather 2-D and 3-D seismic data over large areas. Our interpretation of seismic data delineates for us those portions of an area that we believe are desirable for drilling. Therefore, we may choose not to acquire option or lease rights prior to acquiring seismic data, and in many cases, we may identify hydrocarbon indicators before seeking option or lease rights in the location. If we are not able to lease those locations on

acceptable terms, it would result in our having made substantial expenditures to acquire and analyze 2-D and 3-D data without having an opportunity to attempt to benefit from those expenditures.

 

Drilling for and producing natural gas and oil are high risk activities with many uncertainties that could adversely affect our business, financial condition or results of operations.

 

Our drilling and operating activities are subject to many risks, including the risk that we will not discover commercially productive reservoirs. Drilling for natural gas and oil can be unprofitable, not only from dry holes, but from productive wells that do not produce sufficient revenues to return a profit. In addition, our drilling and producing operations may be curtailed, delayed or canceled as a result of other factors, including:

 

 

Any of these risks can cause substantial losses, including personal injury or loss of life; damage to or destruction of property, natural resources and equipment; pollution; environmental contamination or loss of wells; and regulatory fines or penalties.

 

Insurance against all operational risks is not available to us. Additionally, we may elect not to obtain insurance if we believe that the cost of available insurance is excessive relative to the perceived risks presented. We do not carry environmental insurance, thus, losses could occur for uninsurable or uninsured risks or in amounts in excess of existing insurance coverage. The occurrence of an event that is not covered in full or in part by insurance could have a material adverse impact on our business activities, financial condition and results of operations.

 

Market conditions or operational impediments may hinder our access to natural gas and oil markets or delay our production.

 

Market conditions or a lack of satisfactory natural gas and oil transportation arrangements may hinder our access to natural gas and oil markets or delay our production. The availability of a ready market for our natural gas and oil production depends on a number of factors, including the demand for and supply of natural gas and oil and the proximity of reserves to pipelines and terminal facilities. Our ability to market our production depends in substantial part on the availability and capacity of gathering systems, pipelines and processing facilities. For example, we are currently experiencing capacity limitations in the Piñon Field. Our failure to obtain such services on acceptable terms or expand our midstream assets could materially harm our business. We may be required to shut in wells for a lack of a market or because access to natural gas pipelines, gathering system capacity or processing facilities may be limited or unavailable. If that were to occur, then we would be unable to realize revenue from those wells until production arrangements were made to deliver the production to market.

 

Our development and exploration operations require substantial capital and we may be unable to obtain needed capital or financing on satisfactory terms, which could lead to a loss of properties and a decline in our natural gas and oil reserves.

 

The natural gas and oil industry is capital intensive. We make and expect to continue to make substantial capital expenditures in our business and operations for the exploration, development, production and acquisition of natural gas and oil reserves. To date, we have financed capital expenditures primarily with proceeds from the sale of equity, bank borrowings and cash generated by operations. We intend to finance our future capital expenditures with the sale of equity, asset sales, cash flow from operations and current and new financing arrangements. Our cash flow from operations and access to capital are subject to a number of variables, including:

 

 

If our revenues decrease as a result of lower natural gas and oil prices, operating difficulties, declines in reserves or for any other reason, we may have limited ability to obtain the capital necessary to sustain our operations at current levels. In order to fund our capital expenditures, we must seek additional financing. Our senior credit facility and term loan contain covenants restricting our ability to incur additional indebtedness without the consent of the lenders. Our lenders may withhold this consent in their sole discretion.

 

In addition, we may not be able to obtain debt or equity financing on terms favorable to us, or at all. The failure to obtain additional financing could result in a curtailment of our operations relating to exploration and development of our prospects, which in turn could lead to a possible loss of properties and a decline in our natural gas and oil reserves.

 

We have a substantial amount of indebtedness, which may adversely affect our cash flow and our ability to operate our business.

 

As of September 30, 2007, our total indebtedness was $1.5 billion, which represented approximately 51% of our total capitalization. Our substantial level of indebtedness increases the possibility that we may be unable to generate cash sufficient to pay, when due, the principal of, interest on or other amounts due in respect of our indebtedness. Our substantial indebtedness, combined with our lease and other financial obligations and contractual commitments, could have other important consequences to you. For example, it could:

 

 

Any of the above listed factors could materially adversely affect our business, financial condition and results of operations.

 

Our senior credit facility and term loan have restrictions and financial covenants which could adversely affect our operations.

 

We will depend on our senior credit facility for a portion of future capital needs. The senior credit facility and term loan restrict our ability to obtain additional financing, make investments, lease equipment, sell assets and engage in business combinations. We also are required to comply with certain financial covenants and ratios. Our ability to comply with these restrictions and covenants in the future is uncertain and will be affected by the levels of cash flow from our operations and events or circumstances beyond our control. Our failure to comply with any of the restrictions and covenants under the senior credit facility, term loan or other debt financing could result in a default under those facilities, which could cause all of our existing indebtedness to be immediately due and payable.

 

The senior credit facility limits the amounts we can borrow to a borrowing base amount, determined by the lender in its sole discretion on a semi-annual basis, based upon projected revenues from the natural gas and oil properties securing our loan. The lender can unilaterally adjust the borrowing base and the borrowings permitted to be outstanding under the senior credit facility, and any increase in the borrowing base requires its consent. Outstanding borrowings in excess of the borrowing base must be repaid immediately, or we must pledge other natural gas and oil properties as additional collateral. We do not currently have any substantial unpledged properties, and we may not have the financial resources in the future to make any mandatory principal prepayments required under the senior credit facility.

 

Our derivative activities could result in financial losses or could reduce our earnings.

 

To achieve a more predictable cash flow and to reduce our exposure to adverse fluctuations in the prices of natural gas and oil, we currently, and may in the future, enter into derivative instruments for a portion of our natural gas and oil production, including collars and price-fix swaps. We have not designated any of our derivative instruments as hedges for accounting purposes and record all derivative instruments on our balance sheet at fair value. Changes in the fair value of our derivative instruments are recognized in current earnings. Accordingly, our earnings may fluctuate significantly as a result of changes in fair value of our derivative instruments. Derivative instruments also expose us to the risk of financial loss in some circumstances, including when:

 

 

In addition, these types of derivative arrangements limit the benefit we would receive from increases in the prices for natural gas and oil and may expose us to cash margin requirements.

 

Competition in the natural gas and oil industry is intense, which may adversely affect our ability to succeed.

 

The natural gas and oil industry is intensely competitive, and we compete with companies that have greater resources. Many of these companies not only explore for and produce natural gas and oil, but also carry on refining operations and market petroleum and other products on a regional, national or worldwide basis. These companies may be able to pay more for productive natural gas and oil properties and exploratory prospects or identify, evaluate, bid for and purchase a greater number of properties and prospects than our financial or human resources permit. In addition, these companies may have a greater ability to continue exploration activities during periods of low natural gas and oil market prices. Our larger competitors may be able to absorb the burden of present and future federal, state, local and other laws and regulations more easily than we can, which would adversely affect our competitive position. Our ability to acquire additional properties and to discover reserves in the future will be dependent upon our ability to evaluate and select suitable properties and to consummate transactions in a highly competitive environment. In addition, because

we have fewer financial and human resources than many companies in our industry, we may be at a disadvantage in bidding for exploratory prospects and producing natural gas and oil properties.

 

Downturns in natural gas and oil prices can result in decreased oil field activity which, in turn, can result in an oversupply of service providers and drilling rigs. This oversupply can result in severe reductions in prices received for oil field services or a complete lack of work for crews and equipment.

 

We are subject to complex federal, state, local and other laws and regulations that could adversely affect the cost, manner or feasibility of conducting our operations.

 

Our natural gas and oil exploration, production, transportation and treatment operations are subject to complex and stringent laws and regulations. In order to conduct our operations in compliance with these laws and regulations, we must obtain and maintain numerous permits, approvals and certificates from various federal, state and local governmental authorities. We may incur substantial costs in order to maintain compliance with these existing laws and regulations. In addition, our costs of compliance may increase if existing laws and regulations are revised or reinterpreted, or if new laws and regulations become applicable to our operations. For instance, we may be unable to obtain all necessary permits, approvals and certificates for proposed projects. Alternatively, we may have to incur substantial expenditures to obtain, maintain or renew authorizations to conduct existing projects. If a project is unable to function as planned due to changing requirements or public opposition, we may suffer expensive delays, extended periods of non-operation or significant loss of value in a project. All such costs may have a negative effect on our business and results of operations.

 

Our business is subject to federal, state and local laws and regulations as interpreted and enforced by governmental agencies and other bodies vested with much authority relating to the exploration for, and the development, production and transportation of, natural gas and oil. Failure to comply with such laws and regulations, as interpreted and enforced, could have a material adverse effect on us. For instance, the U.S. Department of the Interior’s Minerals Management Service (“MMS”), may suspend or terminate our operations on federal leases for failure to pay royalties or comply with safety and environmental regulations.

 

Our operations expose us to potentially substantial costs and liabilities with respect to environmental, health and safety matters.

 

We may incur substantial costs and liabilities as a result of environmental, health and safety requirements applicable to our natural gas and oil exploration, development, production, transportation, treatment, and other activities. These costs and liabilities could arise under a wide range of environmental, health and safety laws, that cover, among other things, emissions into the air and water, habitat and endangered species protection, the containment and disposal of hazardous substances, oil field waste and other waste materials, the use of underground injection wells, and wetlands protection. These laws and regulations are complex, change frequently and have tended to become increasingly strict over time. Failure to comply with environmental, health and safety laws or regulations may result in assessment of administrative, civil, and criminal penalties, imposition of cleanup and site restoration costs and liens, and the issuance of orders enjoining or limiting our current or future operations. Compliance with these laws and regulations also increases the cost of our operations and may prevent or delay the commencement or continuance of a given operation. Specifically, we may incur increased expenditures in the future in order to maintain compliance with laws and regulations governing emissions of air pollutants from our natural gas treatment plants. See “Business — Environmental Matters and Regulation.”

 

Under certain environmental laws that impose strict, joint and several liability we may be required to remediate our contaminated properties regardless of whether such contamination resulted from the conduct of others or from consequences of our own actions that were or were not in compliance with all applicable laws at the time those actions were taken. In addition, claims for damages to persons or property may result from environmental and other impacts of our operations. Moreover, new or modified environmental, health or safety laws, regulations or enforcement policies could be more stringent and impose unforeseen liabilities or significantly increase compliance costs. Therefore, the costs to comply with environmental, health or safety

laws or regulations or the liabilities incurred in connection with them could significantly and adversely affect our business, financial condition or results of operations. In addition, many countries as well as several states of the U.S. have agreed to regulate emissions of “greenhouse gases.” Methane, a primary component of natural gas, and carbon dioxide, a byproduct of burning of natural gas and oil are greenhouse gases. Regulation of greenhouse gases could adversely impact some of our operations and demand for some of our services or products in the future. See “Business — Environmental Matters and Regulation.”

 

The inability of one or more of our customers to meet their obligations may adversely affect our financial results.

 

Substantially all of our accounts receivable for natural gas and oil sales, drilling and oil field services and midstream gas services result from billings to third-parties in the energy industry. This concentration of customers and joint interest owners may impact our overall credit risk in that these entities may be similarly affected by changes in economic and other conditions. In addition, our natural gas and oil derivative arrangements expose us to credit risk in the event of nonperformance by counterparties.

 

We have identified a material weakness in our internal control over financial reporting. If additional material weaknesses are detected or if we fail to maintain an adequate system of internal control over financial reporting this could adversely affect our ability to accurately report our results.

 

We are not currently required to comply with Section 404 of the Sarbanes Oxley Act of 2002, and are therefore not required to make an assessment of the effectiveness of our internal controls over financial reporting for that purpose. As disclosed elsewhere in this prospectus and in Note 1 to our consolidated financial statements included in this prospectus, we have restated our consolidated financial statements for our December 31, 2006 year end. We have considered the internal control over financial reporting implications of the error which resulted in the restatement of our consolidated financial statements and determined a material weakness existed as it relates to financial reporting process and accounting for derivatives. See “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Restatement of Previously Issued Financial Statements — Correction of an Accounting Error.”

 

Management is responsible for establishing and maintaining adequate internal control over financial reporting. Our internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements in accordance with generally accepted accounting principles. A material weakness is a control deficiency or a combination of control deficiencies, that results in a more than remote likelihood that a material misstatement of the annual or interim financial statements will not be prevented or detected.

 

Effective internal controls are necessary for us to provide reliable financial reports and effectively prevent fraud. If we cannot provide reliable financial reports or prevent fraud, our reputation and operating results would be harmed. Our efforts to develop and maintain our internal controls may not be successful, and we may be unable to maintain adequate controls over our financial processes and reporting in the future, including future compliance with the obligations under Section 404 of the Sarbanes-Oxley Act of 2002. We will be required to comply with Section 404 of the Sarbanes-Oxley Act of 2002 effective as of December 31, 2008. Any failure to develop or maintain effective controls, or difficulties encountered in their implementation or other effective improvement of our internal controls could harm our operating results. Ineffective internal controls could also cause investors to lose confidence in our reported financial information.

 

Risks Related to Our Common Stock

 

A significant portion of our outstanding shares of common stock may be sold into the market in the near future. This could cause the market price of our common stock to drop significantly.

 

As of November 30, 2007, we had outstanding 141,845,661 shares of common stock. In addition, 22,275,871 shares of common stock will be issuable upon conversion of our outstanding convertible preferred stock. Of these shares, the 59,821,049 shares the selling stockholders are selling in this offering will be freely

tradable without restriction under the Securities Act except for any shares purchased by one of our “affiliates” as defined in Rule 144 under the Securities Act.

 

The resale of these shares in the future could cause the market price of our stock to drop significantly.

 

The market price for shares of our common stock may be highly volatile and could be subject to wide fluctuations.

 

The market price for shares of our common stock may be highly volatile and could be subject to wide fluctuations, even if an active trading market develops. Some of the factors that could negatively affect our share price include:

 

 

We do not anticipate paying any dividends on our common stock in the foreseeable future.

 

We do not expect to declare or pay any cash or other dividends in the foreseeable future on our common stock, as we intend to use cash flow generated by operations to expand our business. Our senior credit facility and term loan restrict our ability to pay cash dividends on our common stock, and we may also enter into credit agreements or other borrowing arrangements in the future that restrict our ability to declare or pay cash dividends on our common stock. In addition, the certificate of designation for our convertible preferred stock prohibits the payment of dividends to holders of our common stock without the consent of holders of a majority of our outstanding convertible preferred stock.

 

You may experience dilution of your ownership interests due to the future issuance of additional shares of our common stock.

 

We may in the future issue our previously authorized and unissued securities, resulting in the dilution of the ownership interests of our present stockholders and purchasers of common stock offered hereby. As of September 30, 2007, we were authorized to issue 400 million shares of common stock and 50 million shares of preferred stock with preferences and rights as determined by our Board of Directors. As of November 30, 2007, we had 141,854,661 shares of common stock outstanding and pursuant to our stock incentive plan, we have also reserved approximately 2.2 million shares of our common stock for future issuance as restricted stock, stock options or other equity-based grants to employees and directors. We may also issue additional shares of our common stock or other securities that are convertible into or exercisable for common stock in connection with the hiring of personnel, future acquisitions, future private placements of our securities for

capital raising purposes or for other business purposes. We have 2,184,287 shares of convertible preferred stock outstanding, which may be converted into 22,275,871 shares of common stock at any time by the holders of such preferred stock or by us at any time following May 7, 2008 upon satisfaction of other conditions. See “Description of Capital Stock — Preferred Stock — Convertible Preferred Stock.” The potential issuance or sale of additional shares of common stock may create downward pressure on the trading price of our common stock.

 

Our certificate of incorporation and bylaws, as well as Delaware law, contain provisions that could discourage acquisition bids or merger proposals, which may adversely affect the market price of our common stock.

 

Our certificate of incorporation authorizes our board of directors to issue preferred stock without stockholder approval. If our board of directors elects to issue preferred stock, it could be more difficult for a third party to acquire us. In addition, some provisions of our certificate of incorporation and bylaws could make it more difficult for a third party to acquire control of us, even if the change of control would be beneficial to our stockholders, including:

 

 

Delaware law prohibits us from engaging in any business combination with any “interested stockholder,” meaning generally that a stockholder who beneficially owns more than 15% of our stock cannot acquire us for a period of three years from the date this person became an interested stockholder, unless various conditions are met, such as approval of the transaction by our board of directors.

CAUTIONARY STATEMENT CONCERNING FORWARD-LOOKING STATEMENTS

 

Various statements contained in this prospectus, including those that express a belief, expectation, or intention, as well as those that are not statements of historical fact, are forward-looking statements. The forward-looking statements may include projections and estimates concerning the timing and success of specific projects and our future production, revenues, income and capital spending. Our forward-looking statements are generally accompanied by words such as “estimate,” “project,” “predict,” “believe,” “expect,” “anticipate,” “potential,” “could,” “may,” “foresee,” “plan,” “goal” or other words that convey the uncertainty of future events or outcomes. The forward-looking statements in this prospectus speak only as of the date of this prospectus; we disclaim any obligation to update these statements unless required by securities law, and we caution you not to rely on them unduly. We have based these forward-looking statements on our current expectations and assumptions about future events. While our management considers these expectations and assumptions to be reasonable, they are inherently subject to significant business, economic, competitive, regulatory and other risks, contingencies and uncertainties relating to, among other matters, the risks discussed under the heading “Risk Factors” and the following:

 

 

USE OF PROCEEDS

 

The selling stockholders will receive all of the proceeds from any sales of our common stock pursuant to this registration statement, and we will not receive any such proceeds. See “Selling Shareholders.”

 

DIVIDEND POLICY

 

We do not anticipate declaring or paying any cash dividends to holders of our common stock in the foreseeable future. We currently intend to retain all available funds and any future earnings for use in the operation and expansion of our business, including exploration, development and acquisition activities. In addition, the terms of our revolving credit facility and term loan restrict our ability to pay dividends to holders of common stock. In addition, the certificate of designation for our convertible preferred stock prohibits the payment of dividends to holders of our common stock without the consent of holders of a majority of our outstanding convertible preferred stock. Accordingly, if our dividend policy were to change in the future, our ability to pay dividends would be subject to these restrictions and our then existing conditions, including our results of operations, financial condition, contractual obligations, capital requirements, business prospects and other factors deemed relevant by our board of directors. In December 2003, we paid a cash dividend on our common stock in the amount of $0.02 per share on the 56,312,400 shares then outstanding.

 

UNAUDITED PRO FORMA CONDENSED COMBINED FINANCIAL STATEMENTS

 

The following unaudited pro forma condensed combined financial information reflects our historical results as adjusted on a pro forma basis to give effect to the NEG acquisition and other 2006 acquisitions and the related financing transactions, which were entered into in order to fund these transactions. The unaudited pro forma condensed combined statements of operations information for the year ended December 31, 2006 and the nine months ended September 30, 2006 give effect to these transactions as if they occurred on January 1, 2006. The pro forma adjustments are based on available information and assumptions that our management believes are reasonable and are described in the related notes.

 

NEG acquisition

 

We acquired all the outstanding membership interests of NEG on November 21, 2006 for approximately $990.4 million in cash, 12,842,000 shares of our common stock (valued at approximately $231.2 million) and the assumption of $300 million in debt, and received $21.1 million in available cash. The cash requirements were funded from the issuance of $550 million in preferred stock, common units and additional banking arrangements.

 

Prior to our acquisition of NEG, NEG acquired the remaining 50% membership interests in NEG Holding LLC that NEG did not already own, and NEG distributed all of its 50.1% capital stock and $148 million senior notes investment in National Energy Group, Inc. (“NEGI”). As a result, we acquired 100% of the membership interests in NEG Holding LLC and no interest in NEGI.

 

Other 2006 acquisitions

 

 

The historical statement of operations information for the year ended December 31, 2006 is derived from our audited consolidated financial statements. The historical statement of operations information for the nine months ended September 30, 2006 is derived from our unaudited condensed consolidated financial statements. We have provided the historical information regarding us and our subsidiaries and the assumptions and adjustments for the pro forma information.

 

The unaudited pro forma condensed combined financial statements are presented for informational purposes only and are not necessarily indicative of the combined results of operations which would have been realized had the transactions been effective for the period presented or the combined results of operations of SandRidge and its subsidiaries (including the entities to be acquired in the NEG acquisition) in the future. The unaudited pro forma condensed combined financial information for the period presented may have been different had the transactions actually been completed during the period due to, among other factors, those factors discussed in “Risk Factors.”

 

You should read the unaudited pro forma condensed combined financial information in conjunction with our historical financial statements and related notes and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” included in this prospectus.

 

SandRidge Energy, Inc.

 

UNAUDITED PRO FORMA CONDENSED COMBINED STATEMENT OF OPERATIONS

FOR THE YEAR ENDED DECEMBER 31, 2006

 

 

See Notes to Unaudited Pro Forma Condensed Combined Financial Information

SandRidge Energy, Inc.

 

UNAUDITED PRO FORMA COMBINED CONSOLIDATED STATEMENTS OF OPERATIONS

FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2006

 

 

See Notes to Unaudited Pro Forma Condensed Combined Financial Information

 

NOTES TO UNAUDITED PRO FORMA CONDENSED COMBINED FINANCIAL INFORMATION

 

Basis of Presentation

 

The unaudited pro forma condensed combined statements of operations for the year ended December 31, 2006 and the nine months ended September 30, 2006 give effect to the NEG acquisition and the other 2006 acquisitions and the related financing transactions as if they occurred on January 1, 2006.

 

NEG’s combined financial statements include the accounts of NEG and subsidiaries excluding NEGI, and the 103/4% Senior Notes due from NEGI, but including NEGI’s 50% membership interest in NEG Holding LLC, from January 1, 2006 through November 21, 2006, the date of the NEG acquisition for purposes of the pro forma condensed combined statement of operations for the year ended December 31, 2006 and January 1, 2006 through September 30, 2006 for purposes of the pro forma condensed combined statement of operations for the nine months ended September 30, 2006.

 

The unaudited pro forma condensed combined statements of operations for the year ended December 31, 2006 and the nine months ended September 30, 2006 have been prepared based on the following information:

 

(a) audited consolidated financial statements of SandRidge and its subsidiaries as of and for the year ended December 31, 2006;

 

(b) unaudited condensed consolidated financial statements of SandRidge and its subsidiaries as of and for the nine months ended September 30, 2006; and

 

(c) other supplementary information we considered necessary for the purpose of reflecting the transactions contemplated in the pro forma combined financial statements.

 

We accounted for this acquisition using the purchase method of accounting for business combinations. Under the purchase method of accounting, we are deemed to be the acquirer for accounting purposes based on a number of factors determined in accordance with GAAP. The purchase method of accounting requires the assets we acquired and liabilities we assumed to be recorded at their estimated fair values.

 

For purposes of these pro forma condensed combined financial statements, the presentation of certain historical NEG financial information has been modified to conform to this pro forma presentation.

 

Statement of Operations Adjustments

 

(a) Reflects the pro forma elimination of activity between us and NEG. We provided services to NEG as the operator of certain oil and gas properties and also provided other services to NEG.

 

(b) Reflects the increase in revenues and expenses related to the other 2006 acquisitions of $5.2 million in revenues and $1.5 million in production expenses. These acquisitions were completed by September 30, 2006.

 

(c) Reflects a $97.0 million and $81.7 million incremental increase in depletion expense resulting from the step-up of property, plant and equipment acquired based on the allocation of the purchase price to the properties’ fair value at December 31, 2006 and September 30, 2006, respectively. Adjustment assumes no material changes in the estimated lives or amortization periods for acquired assets as a result of the purchase price allocation.

 

(d) Reflects adjustment to increase interest expense for the effect of the additional debt assumed from the merger and the amounts borrowed as well as to recognize amortization expense associated with our estimated debt issuance costs. The interest rate used in the calculation of interest expense is monthly LIBOR plus 4.5%, the expected actual interest rates, and the life used in the calculation of amortization expense is based on the expected life of the new debt. If the actual interest rate is 1/8% more or less than the assumed rate, the interest

cost will increase or decrease by approximately $0.5 million for the year ended December 31, 2006 and $0.4 million for the nine months ended September 30, 2006.

 

(e) Reflects the net pro forma adjustment to minority interest as a result of the acquisition of additional interests in PetroSource in our financial statements.

 

(f) Reflects adjustment to income tax expense to reflect total combined pro forma income tax expense at a 37% statutory income tax rate as NEG was organized as a limited liability company for the period presented, thus not subject to corporate taxes.

 

(g) Reflects preferred dividends of 7.75% per annum and accretion on convertible preferred stock.

 

(h) Reflects shares issued for the NEG and other 2006 acquisitions adjusted for the inclusion of weighted average share amounts at December 31, 2006 and September 30, 2006.

 

Year ended December 31, 2006

 

Shares issued for the NEG and other 2006 acquisitions are as follows (in thousands):

 

 

Nine months ended September 30, 2006

 

Shares issued for the NEG and other 2006 acquisitions are as follows (in thousands):

 

 

(i) Reflects the issuance of 32,379,500 shares on November 9, 2007.

 

SELECTED CONSOLIDATED HISTORICAL FINANCIAL DATA

 

Set forth below is our selected consolidated historical financial data for the periods indicated. The historical statement of operations data for the periods ended December 31, 2002, 2003, 2004, 2005 and 2006 and the balance sheet data as of December 31, 2002, 2003, 2004, 2005 and 2006 have been derived from our audited financial statements. Our historical statement of operations data as of and for the nine months ended September 30, 2006 and 2007 are derived from our unaudited financial statements and, in our opinion, have been prepared on the same basis as the audited financial statements and include all adjustments, consisting of normal recurring adjustments, necessary for a fair statement of this information. You should read the following summary financial data in conjunction with “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and our historical and pro forma financial statements and related notes thereto appearing elsewhere in this prospectus.